Methods for controlling souring in engineered systems

Patent metadata

Field	Value
Publication number	US-2017198196-A1
Application number	US-201515316816-A
Country	US
Kind code	A1
Filing date	Jun 5, 2015
Priority date	Jun 6, 2014
Publication date	Jul 13, 2017
Grant date	—

Abstract

The present disclosure relates generally to methods for controlling souring in engineered systems, and more specifically to methods of controlling souring using chemical, physical, and combinatorial treatments of engineered systems to reduce hydrogen sulfide-associated souring in such engineered systems, such as oil reservoirs.

First claim

What is claimed is:

1 . A method for controlling souring comprising contacting an engineered system comprising a souring-promoting microbial community with a composition comprising monofluorophosphate at a concentration sufficient to inhibit souring in a unit volume of the engineered system.

2 . The method of claim 1 , wherein the engineered system is an oil reservoir.

3 . The method of any one of claim 1 or 2 , wherein the composition comprising monofluorophosphate is an aqueous solution of a salt of monofluorophosphate.

4 . The method of claim 3 , wherein the salt of monofluorophosphate is selected from the group consisting of sodium salts, ammonium salts, potassium salts, and calcium salts of monofluorophosphate.

5 . The method of any one of claims 1 - 4 , wherein the concentration of the monofluorophosphate present in the engineered system is in the range of about 0.1 mM to about 5 mM.

6 . The method of claim 5 , wherein the concentration of the monofluorophosphate present in the engineered system is about 0.8 mM.

7 . The method of any one of claims 1 - 6 , wherein the microbial community comprises both sulfate-reducing microorganisms and non-sulfate-reducing microorganisms.

8 . The method of claim 7 , wherein the monofluorophosphate in the engineered system does not significantly impact the general metabolism of the non-sulfate-reducing microorganisms.

9 . The method of any one of claims 1 - 8 , wherein souring in a unit volume of the engineered system is inhibited by about 50% or more as compared to a corresponding unit volume in a system not contacted with monofluorophosphate.

10 . The method of claim 9 , wherein souring is assayed by measuring parameters selected from the group consisting of hydrogen sulfide production, fluid contamination, metal corrosion, and clogging of the engineered system.

11 . The method of any one of claims 1 - 10 , wherein the method further comprises contacting the engineered system with a second composition comprising an additional souring inhibitor.

12 . The method of claim 11 , wherein the second composition comprises nitrate or (per)chlorate.

13 . A method for controlling souring comprising contacting an engineered system comprising a souring-promoting microbial community with a heated fluid at a temperature sufficient to inhibit souring in a unit volume of the engineered system.

14 . The method of claim 13 , wherein the engineered system is an oil reservoir.

15 . The method of any one of claim 13 or 14 , wherein the temperature of the heated fluid present in the engineered system is at least about 60° C.

16 . The method of claim 15 , wherein the temperature of the heated fluid present in the engineered system is about 125° C. or more.

17 . The method of any one of claims 13 - 16 , wherein the heated fluid comprises seawater.

18 . The method of any one of claims 13 - 17 , wherein souring in a unit volume of the engineered system is inhibited by about 50% or more as compared to a corresponding unit volume in a system not contacted with the heated fluid.

19 . The method of claim 18 , wherein souring is assayed by measuring parameters selected from the group consisting of hydrogen sulfide production, fluid contamination, metal corrosion, and clogging of the engineered system.

20 . The method of any one of claims 13 - 19 , wherein the unit volume comprises at least 90% of the total volume of the engineered system.

21 . The method of any one of claims 13 - 20 , wherein the method further comprises contacting the engineered system with a composition comprising a souring inhibitor.

22 . The method of claim 21 , wherein the composition comprises a compound selected from the group consisting of monofluorophosphate, nitrate, and (per)chlorate.

23 . A method for controlling souring comprising contacting an engineered system comprising a souring-promoting microbial community with:
a composition comprising a souring inhibitor, and; a heated fluid, wherein the concentration of the souring inhibitor and the temperature of the heated fluid are sufficient to inhibit souring in a unit volume of the engineered system.

24 . The method of claim 23 , wherein the engineered system is an oil reservoir.

25 . The method of any one of claim 23 or 24 , wherein the souring inhibitor is selected from the group consisting of monofluorophosphate, nitrate, and (per)chlorate.

26 . The method of claim 25 , wherein the souring inhibitor is monofluorophosphate and wherein the concentration of the monofluorophosphate present in the engineered system is in the range of about 0.1 mM to about 5 mM.

27 . The method of any one of claims 23 - 26 , wherein the temperature of the heated fluid present in the engineered system is about 60° C. or more.

28 . The method of claim 27 , wherein the heated fluid comprises seawater.

29 . The method of any one of claims 23 - 28 , wherein souring in a unit volume of the engineered system is inhibited by about 50% or more as compared to a corresponding unit volume in a system not contacted with the inhibitor of souring or the heated fluid.

30 . The method of claim 29 , wherein souring is assayed by measuring parameters selected from the group consisting of hydrogen sulfide production, fluid contamination, metal corrosion, and clogging of the engineered system.

31 . A method for controlling souring comprising contacting an engineered system comprising a souring-promoting microbial community with a cooled fluid at a temperature sufficient to inhibit souring in a unit volume of the engineered system.

32 . The method of claim 31 , wherein the engineered system is an oil reservoir.

33 . The method of any one of claim 31 or 32 , wherein the temperature of the cooled fluid present in the engineered system is below 0° C.

34 . The method of any one of claims 31 - 33 , wherein the cooled fluid comprises seawater.

35 . The method of any one of claims 31 - 34 , wherein souring in a unit volume of the engineered system is inhibited by about 50% or more as compared to a corresponding unit volume in a system not contacted with the cooled fluid.

36 . The method of claim 35 , wherein souring is assayed by measuring parameters selected from the group consisting of hydrogen sulfide production, fluid contamination, metal corrosion, and clogging of the engineered system.

37 . The method of any one of claims 31 - 36 , wherein the unit volume comprises at least 90% of the total volume of the engineered system.

38 . The method of any one of claims 31 - 37 , wherein the method further comprises contacting the engineered system with a composition comprising a souring inhibitor.

39 . The method of claim 38 , wherein the composition comprises a compound selected from the group consisting of monofluorophosphate, nitrate, and (per)chlorate.

40 . A method for controlling souring comprising contacting an engineered system comprising a souring-promoting microbial community with:
a composition comprising a souring inhibitor, and; a cooled fluid, wherein the concentration of the souring inhibitor and the temperature of the cooled fluid are s

Assignees

• Univ California
• Bp Corp North America Inc

Inventors

• Coates John D
• Carlson Hans
• Engelbrektson Anna
• Mullan Mark
• Carrera Martin E

Classifications

• E21B37/06

  using chemical means for preventing or limiting {, e.g. eliminating,} the deposition of paraffins or like substances · CPC title

• C09K8/54

  Compositions for in situ inhibition of corrosion in boreholes or wells · CPC title

• E21B36/00

  Heating, cooling or insulating arrangements for boreholes or wells, e.g. for use in permafrost zones · CPC title

• E21B41/02

  in situ inhibition of corrosion in boreholes or wells · CPC title

• C09K2208/20

  Hydrogen sulfide elimination · CPC title